Method for the conversion of hydrocarbons



Jan. 13,1970 w. B. BORST, JR

METHOD FOR THE CONVERSION OF HYDROCARBONS wasmm w w 9 2 w M d e l H tsmm asmm v ww Qm\ R mm 5% (ISO/J 10H low/odes ,10

Will/am B. Borsl, Jr.

A TTO/P/VEYS United States Patent M US. Cl. 208-108 7 Claims ABSTRACT OF THE DISCLOSURE Method for hydrodesulfurizing hydrocarbons preferably boiling up to about 1100 F. by subjecting feed hydrocarbons to reaction with hydrogen over hydrogenation catalyst so that the feed hydrocarbons are at least mildly hydrocracked and substantially desulfurized. The reactor effluent is quenched with a specific liquid hydrocarbon stream which had been previously separated from the reaction zone effiuent product. The amount of quench is responsive to the measurement of the temperature of the vapor stream out of the high pressure separator immediately following the reaction zone such that a predetermined temperature thereof (below about 800 F.) is maintained in this vapor stream. Hydrocarbon products of reduced content are subsequently recovered.

BACKGROUND OF THE INVENTION This invention relates to the conversion of hydrocarbons. It particularly relates to the hydrogenation of relatively high boiling hydrocarbons by catalytic exothermic reaction with a normally gaseous reactant. It specifically relates to a method for hydrocracking black oil hydrocarbons by an improved manner of quenching the hydrocracking reaction.

It is well known in the art that conversion reactions, in general, and hydrocracking reactions, specifically are exothermic in nature; that is, the reaction releases significant quantities of heat which must be selectively disposed of if the reaction is to be controlled and optimum results are to be obtained. There have been a variety of prior art schemes proposed for such reactions and, in general, these embody indirect heat exchange schemes wherein the heated efiiuent is exchanged with a relatively cold material, such as incoming feedstock, so that the efliuent temperature does not exceed a predetermined value and preheat of the feed is achieved.

It has now been found that there are other aspects for achieving economical thermal balance around an exothermic reaction zone which must be considered in devising a suitable quench mechanism.

SUMMARY OF THE INVENTION Therefore, it is an object of this invention to provide an improved method for the conversion of hydrocarbons.

It is also an object of this invention to provide a method for quenching an exothermic conversion reaction.

It is a specific object of this invention to provide a method for hydrocracking relatively high boiling hydrocarbons in a facile and economical manner.

Accordingly, the method of the present invention comprises introducing feed hydrocarbons into a catalytic reaction zone maintained under conversion conditions, including the presence of hydrogen gas; passing the total efiiuent from said zone into a first separation zone under conditions suflicient to produce a first vapor stream, and a first liquid stream containing converted hydrocarbon; measuring the temperature of said first vapor stream; 1ntroducing hereinafter specified quench stream directly into the downstream side of said reaction zone in an amount 3,489,674 Patented Jan. 13, 1970 responsive to said temperature measurement sufiicient to maintain a predetermined temperature of said first vapor stream; cooling said first vapor stream to a temperature within the range from 50 F. to F.; separating the cooled vapor stream in a second reaction zone under conditions sufficient to provide a second reaction zone under conditions sufiicient to provide a second vapor stream comprising hydrogen, and a second liquid stream containing converted hydrocarbons; passing at least a portion of said second vapor stream into indirect heat exchange with a portion of said first liquid stream, thereby cooling said liquid portion and heating said gaseous portion; passing said cooled portion as quench into said downstream side as specified; returning said heated gaseous portion to said reaction zone; and, recovering converted hydrocarbons in high concentration.

Another embodiment of the invention includes the method wherein said predetermined temperature is less than about 800 F. and more than 700 F.

As previously mentioned, the present invention relates broadly to the conversion of hydrocarbons. Therefore, as used herein, the term conversion is intended to include the saturation of olefinic hydrocarbons, desulfurization, denitrogenation, cracking, etc. of hydrocarbons. In short, this term includes any exothermic reaction which operates by reacting a normally gaseous reactant, such as hydrogen, with at least a portion of a suitable feedstock. Similarly, the terms converted hydrocarbons and hydrogenated hydrocarbons are intended to include any hydrocarbons which have passed through the catalytic reaction zone, even though such hydrocarbons, per se, were substantially unchanged in the reaction. Thus, a converted (or hydrogenated) product would be one which has a reduced sulfur content, even though to a considerable extent the hydrocarbons have passed through the reaction zone substantially unchanged. In the illustrative embodiment of the invention, more fully discussed hereinbelow, the term conversion and the term hydrogenation are used interchangeably to describe the hydrocracking of relatively high boiling hydrocarbon feedstocks with simultaneous desulfurization of such feedstocks.

It was noted from the broad embodiment of the invention that the quench is introduced into the downstream side of the reaction zone. This term is intended to include the introduction of quench into the lower portion of the catalyst bed, into the lower end of the reactor vessel and/or into the transfer line between the reactor vessel and the next succeeding vessel which is normally a high pressure separator. The term excludes a locus for quench which is into the catalyst bed wherein significant reaction is taking place and excludes the introduction of quench directly into the high pressure separator vessel. It is preferable that the quench be introduced into the lower end of the reactor vessel below the catalyst bed to form a physical admixture with the effluent.

The present invention is uniquely applicable to hydrocarbon conversion methods which may be characterized as hydrogen consuming and in which a large excess of hydrogen gas reactant is maintained in the reaction zone, thereby necessitating the recovery and recycle of a hydrogen-rich vapor stream in order for economy of operation to be achieved. In many instances, it is also desirable to recycle with the feedstock at least a portion of the normally liquid product efiiuent; which recycle acts as a diluent stream and/or is subjected to further conversion in order to increase the yield of converted products from the reaction.

The present invention is distinctly applicable to the hydrocracking reaction which is utilized by the petroleum refining art to convert relatively heavy carbonaceous material into lower boiling (or lower molecular weight) hydrocarbon products such as gasoline and/or fuel oil, and the like. In other instances, the hydrocracking reaction is used for the production of liquefied petroleum gas (LPG). Hydrocracking also includes the processing of heavy residual stocks commonly called black oils. These black oils include atmospheric tower bottoms products, vacuum tower bottoms products (vacuum residuum), crude oil residuum reduced crude oils, synthetic crude oils obtained from tar sands or oil shale, etc.

Similarly, the present invention is applicable to the conversion of relatively heavy hydrocarbons such as those having initial boiling points above about 400 F. and end boiling points of about 1100 F. With specific reference to the black oils, this class of relatively heavy hydrocarbons are characterized by having at least 10% and, preferably, from 50% to 90% by volume boiling above about 1050 F. Normally, in hydrogenating such feedstocks as herein mentioned there is, in addition to the hydrocracking reaction, the desulfurization reaction which converts sulfur compounds into hydrogen sulfide and the denitrogenation reaction which converts nitrogen compounds into ammonia.

Specific feedstocks which may be processed in accordance with this invention include a vacuum tower bottoms product having a gravity of 7 .1 API at 60 F., and containing 4.1% by weight sulfur and 23.7% by weight asphaltic compounds; a reduced crude oil having a gravity of 11 API at 60 F., and containing 10.1% by weight of asphaltic compounds and about 5.2% by weight sulfur; and a vacuum residuum having a gravity of about 8.8 API at 60 F., and containing 3.0% by weight sulfur and 4300 p.p.rn. (parts per million by weight) of nitrogen, and having a 20.0% volumetric distillation point of 1055 F. Generally, the asphaltic compounds are found to be colloidally dispersed within the black oil, and when subjected to elevated temperature and pressure has a tendency to flocculate and/or polymerize, whereby the conversion thereof to more valuable products becomes extremely difiicult.

In the processing of black oils the conversion conditions are those which are sufiicient for the purpose of achieving both desulfurization and conversion of at least a portion of the feed hydrocarbons into lower boiling (or lower molecular weight) hydrocarbon products. Generally, these conversion conditions are significantly less severe than those being currently commercially employed in processing similar charge stocks. For example, with respect to black oil processing, the conversion conditions include a temperature from 700 F. to 900 F. and a pressure from 1000 p.s.i.g. to 3500 p.s.i.g. The temperature usually is measured at the inlet to the catalyst bed since the exothermic nature of the reaction will produce a considerably higher effluent temperature. For example, the efiluent temperature, in the absence of quench, may be as high as 900 F. even though the inlet feed temperature was only about 725 F. Hydrogen is added to the reaction zone in an amount from 1,000 to 30,000 standard cubic feet per barrel, preferably, from about 2,000 to 10,000 s.c.f./bbl. at the selected operation pressure. The liquid hourly space velocity (volume of hy drocarbon per hour per volume of catalyst) may be selected over a relatively broad range, but, generally, will be within the range from about 0.25 to about 2.0.

The hydrogenation reaction is carried out in the presence of a catalyst. The catalyst is characterized as comprising a metallic component possessing hydrogenation activity. This metallic component is generally composited with a refractory inorganic oxide carrier material which may be of synthetic or natural origin. The precise composition and method of manufacturing the catalyst is not considered an essential element of the present invention; however, a siliceous carrier, such as 88% by weight of alumina and 12% by weight of silica, or 63% by weight alumina and 67% by weight silica, are generally preferred in use in the design to convert black oils into more valuable products. Suitable metallic components, having hydrogenation activity, are those selected from the group of metals of Groups VI-B and VIII of the Periodic Table as indicated in the Periodic Chart of the Elements, Fischer Scientific Company, 1953. Thus, the catalytic composite may comprise one or more metallic components from the group consisting of molybdenum, tungsten, chromium, iron, cobalt, nickel, platinum, palladium, iridium, osmium, rhodium, ruthenium, and mixtures thereof. The concentration of the catalytically active metallic component or components is dictated by the particular metal chosen as well as the physical and chemical characteristics of the black oil charge stocks. The metallic components of Group VI-B are generally present in an amount within the range of about 1.0% to about 20.0% by Weight; the iron group metals in an amount from 0.2% to 10% by weight; and, the platinum group metals are preferably present in an amount from 0.1% to about 5% by weight; all of which are calculated as if the components existed within the finished catalytic composite as the elemental metal.

The refractory inorganic oxide carrier material may comprise alumina, silica, zirconia, magnesia, titania, boria, strontia, hafnia, and mixtures of two or more including silica-alumina, alumina-silica-boria phosphate, silica-zirconia, silica-magnesia, silica-titania, alumina-zirconia, alumina-magnesia, alumina-titania, magnesia-zirconia, siliea-alumina-Inagnesia, silica-altunina-titania, silica-magnesia-zirconia, silica-alumina-boria, etc. It is preferred to utilize a carrier material containing at least a portion of silica and preferably a composite of alumina and silica, with alumina being of the greater proportion.

As previously noted, it was discovered in the practice of this invention that the measurement of the temperature in the first vapor stream from the hot separator is a particularly advantageous control point for the amount of quench necessary. It was further found that the predetermined temperature of this vapor stream from the high pressure separator should be maintained below a temperature of about 800 F., but, preferably, above about 700 F. It was found that at temperatures above about 800 F. the heavier normally liquid hydrocarbons carried over into this vapor phase, thereby considerably contaminating, among other streams, the hydrogen gas stream which subsequently is to be recycled to the reaction zone. If a large amount of the heavier material is carried over into this vapor stream, the size and operating expense of condensing and thereby removing the hydrocarbons from the hydrogen gas would be significantly increased. In addition, it was found that the use of this vapor stream for the control point permitted the complete elimination of all other heat exchange equipment between the reactor vessel and the high pressure separator. Thus, the subsequently separated hydrogen gas is available for recycle at significantly higher pressures than would be the case for prior art schemes using indirect heat exchange means between the reactor vessel and high pressure separator. Obviously, savings in compressing cost can be realized. In other words, the practice of this invention permits the use of solely a direct quench stream, as herein defined, to control this important temperature.

On the other hand, if the temperature of the vapor stream from the high pressure separator is below about 700 F. ammonia salts resulting from the conversion of nitrogenous compounds contained in the feedstock would tend to contaminate the normally liquid hydrocarbon phase from the bottom of the high pressure hot separator. If such were allowed to happen, the conventional way of removing these ammonia salts would be by water washing; however, it is presently believed that if an attempt were made to water wash these relatively heavy converted hydrocarbons an emulsion would be formed by the hydrocarbon and the Water wash which would be extremely difficult to break. Therefore, as more fully discussed hereinbelow, the preferred embodiment of this invention teaches that the control of a predetermined temperature level for the vapor stream leaving the high pressure separator should be less than about 800 F. and more than 700 F. However, depending upon the characteristics of the hydrocarbon feedstock and the conversion conditions chosen, reasonable exceptions to these temperature limitations may be utilized with satisfactory operating results.

ILLUSTRATIVE DRAWING Other operating conditions and the preferred operating technique will be given in conjunction with the following description of one embodiment of the invention with specific reference to the drawing which is a diagrammatic representation of apparatus for practicing one embodiment of the invention.

For the purpose of referring to the drawing, it will be assumed that the method will be operated with the conversion of a reduced crude oil having a gravity of 16.6 API at 60 F. and an ASTM 65.0% volumetric distillation temperature of 1034 F. This reduced crude feedstock contains about 3.8% by weight sulfur, about 2000 ppm. of nitrogen, about 6.5% by weight pentane-insoluble asphaltic materials, a Conradson Carbon residue of about 8.0% by weight and about 85 ppm. of metals principally nickel and vanadium.

Now, with reference to the drawing, the reduced crude enters the method or process system through line 1. It is admixed with make-up hydrogen of about 97.5 mol percent purity from an external source via line 2. It has been found appropriate in some instances to add water to the reaction zone in admixture with the charge stock. When this is deemed advisable, the water is added via line 3.

Normally, however, the use of water is not necessary or desirable.

The hydrogen-reduced crude mixture is further admixed with a hydrogen-rich recycle vapor stream (about 80.0 mol percent hydrogen) from line 4. The total charge after suitable heat exchange with various streams, not shown, is passed through heater 5 to raise the temperature of the charge mixture to about 705 F. In the practice of this embodiment it is preferred that the heated mixture in line 6 be further admixed with a hot (750 F.) recycle stream from line 7 to produce a total reactor charge mixture of about 720 F. and a pressure of about 2165 p.s.i.g.

The heated feedstock in admixture with hydrogen is now passed via line 6 into conversion reactor 8 which contains catalyst disposed therein as a fixed bed; such catalyst being a composite of 2.0% by weight nickel, 16.0% by weight molybdenum on a carrier material comprising 68.0% by weight alumina, 22.0% by weight boron trifluoride, and 10.0% by weight silica. The hydrocarbon phase contacts the catalyst at a liquid hourly space velocity of about 8, based on the original reduced crude oil, or about 2, based on the combined hydrocarbon feed.

The total conversion product effluent leaves reactor 8 via line 9 in admixture with a hereinafter specified quench stream which has been added to the effluent via line 35 at a temperature from 200 F. to 450 F., typically, at about 300 F. Therefore, in line 9 there is the total conversion product efiiuent admixed with the quench stream which had been added via line 35. Prior to the introduction of the quench stream the conversion product etfluent is at a temperature of about 900 F. and a pressure of about 2075 p.s.i.g. Suflicient quench is added via line 35 to lower the temperature of the efliuent stream to less than 800 F., but, preferably, no lower than 700 F. prior to entering hot separator 10. Due to the pressure drop through the transfer line, primarily, the pressure within hot separator 10 is about 2060 p.s.i.g. A first liquid stream is withdrawn from separator 10 through line 11 and a portion of this liquid stream is diverted through line 7 to combine with the heated mixture in line 6 as previously mentioned. Another portion of the first liquid stream continues through line 11 into hot flash zone 24. Still another portion of the first liquid stream is passed via line 35 into heat exchanger 38 as the specified quench stream. Further discussion of this material will be hereinafter.

A first vapor stream is removed from hot separator 10 through line 12. The temperature of this first vapor stream is measured by temperature recording control device (TRC) 36 which opens or closes control valve 37 in accordance with the deviation of the measured temperature from a predetermined temperature (say, 745 F.) for this first vapor stream. Thus, if the measured temperature in line 12 is 760 F. TRC 36 would open control valve 37, thereby increasing the flow of liquid quench in line 35 in an amount sufiicient to maintain the ultimate temperature of the vapor stream in line 12 at its predetermined level of, say, 745 F. After passing the temperature measurement point, the first vapor stream passes through condenser 13 whereby the temperature is lowered to about F. with the pressure now being about 2005 p.s.i.g., again due to the pressure drop through the system.

The various streams flowing into and out of hot separator 10 may have the following illustrative composition (exclusive of quench material):

It should be noted that the 19 mols/hour of water in the reaction zone effluent is water of saturation in the recycle hydrogen gas stream and/or is water present in the fresh hydrogen added to the system by means of line 2 and/or water carried in with the feed hydrocarbons.

The cooled first vapor stream passes through line 14 where, preferably, it is admixed with a portion of a fourth liquid stream in line 23 hereinafter described, and the resulting admixture is introduced into cold separator 15. A second vapor stream containing about 80.0 mol percent hydrogen is removed via line 16, is raised to a pressure of about 2245 p.s.i.g. via compressor 17, and is passed via line 4 though heat exchanger 38 in indirect heat exchange with the portion of the liquid stream in line 7, previously mentioned. After picking up heat through exchanger 38, this hydrogen gas stream passes via line 4 into admixture with the incoming feedstock, as previously mentioned, prior to being introduced into heater 5. If desired, a portion of the hydrogen gas in line 4 may be diverted via line 39 directly in admixture with the incoming feed, thereby by-passing heat exchanger 38. Also, as previously mentioned, if water is added to the feedstock via line 3, then the water may be removed from the system via line 34 from cold separator 15 as indicated on the drawing.

It should be noted at this point that the control of the quench stream is based upon the indirect heat exchange between the hydrogen recycle gas and a portion of the hot separator liquid material flowing in line 7. The control of the amount of the liquid quench utilized via line 35 is based upon a temperature measurement in the vapor stream in line 12 which controls valve 35. It was discovered that this control sequence enabled excellent control and flexibility over the temperature of the effluent entering hot separator 10.

In conjunction with the material balance around hot separator 10, the various streams into and out of cold separator 15 may have the following illustrative composition:

Line No.

Component, mots/hour:

Water 1 091 19 Ammonia 2 0 0 Hydrogen sulfidenu 2, 654 1, 957 697 Hydrogen 18, 371 18, 206 165 Methane. 509 2, 372 137 Ethane.-. 190 158 41 Propane. 187 128 59 Iso-butana. 38 21 17 88 44 44 1 972 molslhour of water injection for ammonia removal. This, along with the 29 mols/hour of ammonia are removed via line 34.

Thus, the liquid stream (line 18) comprises hydrocarbons boiling for the most part below 650 F. (about 78 mol percent 650 F.-hydrocarbons) The portion of first liquid stream in line 11 not utilized as recycle or quench enters hot flash zone 24 at a temperature of about 745 F. and is at a substantially reduced pressure of about 100 p.s.i.g. to 500 p.s.i.g., typically, about 220 p.s.i.g A third liquid stream is removed via line 27 to be combined with a fourth liquid stream, hereinafter described as the major product stream.

A third vapor stream is removed through line 25, is cooled and condensed to about 105 F. in condenser 26 and then passed into cold flash separator 20 through line 19; however, it is to be noted that the cooled third vapor stream is preferably combined with the second liquid stream in line 18 from cold separator 15. The total material entering cold flash separator 20 via line 19 is at a pressure of about 200 p.s.i.g. and a temperature of about 105 F.

A fourth vapor stream comprising, for example, 97.5 mol percent propane and lighter normally gaseous components is removed from separator 20 via line 21. Since this material contains a considerable quantity of hydrogen sulfide, it is generally subjected to a suitable treating process prior to being vented and/or being burned as flue gas. The particular economic aspects to be considered will dictate when the fourth vapor stream (line 21) is suitably treated to recover the small quantities of 04+ normally liquid hydrocarbons contained therein. A fourth liquid stream is removed from cold flash zone 20 via line 22 and a portion thereof is diverted through line 23 to be combined with the cold first vapor stream in line 14 thereby forming the total feed stream to cold separator 15. The remaining amount of the fourth liquid stream is combined with the third liquid stream in line 27 and passed to heater 28, and then, via line 29 into distillation tower 30. It is to be understood that the third liquid stream in line 27 is combined with the unrecycled portion of the fourth liquid stream in line 22 for illustrative purposes only. For reasons peculiar to the particular operation involved, these streams may be separately fractionated to recover desired converted hydrocarbons therefrom.

Distillation column 30 will be operated at conditions of temperature and pressure sufficient to separate the desired fractions of converted hydrocarbons. The particular operating conditions will be known to those skilled in the art from general knowledge and from the teachings presented herein. However, for illustrative purposes, a gasoline boiling range material having an end boiling point of about 380 F. is removed from column 30 via line 31. A middle distillate fraction (380 F. to 650 F.) is also removed via line 32, and, finally, since the primary object of this example was to maximize the production of fuel oil (650 F.+) having a sulfur concentration not greater than 1.0% by weight, a converted hydrocarbon bottoms product is removed from fractionator 30 via line 33.

Therefore, it can be seen from the above specific and illustrative embodiment that the present invention provides a method for hydrogenating (hydrocracking) a relatively heavy hydrocarbon feedstock in a facile and economical manner. The use of a relatively light hydrocarbon liquid stream as quench (line 35) is particularly advantageous in that it is cooled and at a pressure substantially sufiicient for introduction into the reactor efiluent with ut significant additional high pressure pumping. The use of this stream also permits the complete elimination of heat exchange equipment in the transfer line between reactor 8 and hot separator 10 so that maximum pressure may be maintained through the separation steps in such a manner that the recovered hydrogen-containing stream (line 16) may be advantageously reused in the process.

PREFERRED EMBODIMENT Thus, from the description presented hereinabove, the preferred embodiment of the invention provides a method for hydrogenating a sulfur-containing hydrocarbon feedstock which comprises the steps of: (a) introducing said feedstock at an inlet temperature from 700 F. to 800 F. into a reactor vessel containing hydrogenating catalyst disposed as a fixed bed therein maintained under hydrogenating conditions including the presence of hydrogen and a relatively high pressure; (b) withdrawing from said vessel an effluent stream containing hydrogenated hydrocarbons; (c) passing said etfluent stream into a first separation zone under substantially the same pressure as maintained in said reactor vessel to produce a first vapor stream and a first liquid stream containing hydrogenated hydrocarbons; (d) measuring the temperature of said first vapor stream; (e) introducing hereinafter specified liquid quench stream at a temperature from 200 F. to 450 F. directly into the downstream side of said catalyst bed in an amount responsive to said temperature measurement sufiicient to maintain said first vapor fraction at a temperature from 700 F. to 800 F.; (f) cooling said first vapor stream to a temperature from 50 F. to F.; (g) separating the cooled vapor stream in a second separation zone at substantially the same pressure as said first separation zone under conditions sufficient to provide a second vapor stream comprising hydrogen, and a second liquid stream containing hydrogenated hydrocarbons; (h) passing a portion of said first liquid stream into indirect heat exchange with at least a portion of said second vapor stream thereby heating said second vapor stream and cooling said first liquid stream; (i) introducing said cooled liquid stream as quench into said downstream side as specified hereinabove in Step (e); (j) recycling said heated second vapor stream to said reactor vessel of Step (a); (k) recycling another portion of said first liquid stream of Step (c) to combine with said feedstock in Step (a); and, (l) recovering hydrogenated hydrocarbons in high concentration having reduced sulfur content.

What is claimed is:

1. Method for converting hydrocarbons which comprises introducing feed hydrocarbons into a catalytic reaction zone maintained under conversion conditions including the presence of hydrogen gas; passing the total effluent from said zone into a first separation zone under conditions suflicient to produce a first vapor stream, and a first liquid stream containing converted hydrocarbons; measuring the temperature of said first vapor stream; introducing hereinafter specified quench stream directly into the downstream side of said reaction zone in an amount responsive to said temperature measurement suflicient to maintain a predetermined temperature of said first vapor stream; cooling said first vapor stream to a temperature within the range from 50 F. to 150 F.; separating the cooled vapor stream in a second separation zone under conditions suflicient to provide a second vapor stream comprising hydrogen, and a second liquid stream containing converted hydrocarbons; passing at least a portion of said second vapor stream into indirect heat exchange with a portion of said first liquid stream thereby cooling said liquid portion and heating said gaseous portion; passing said cooled portion as quench into said downstream side as specified; returning said heated gaseous portion to said reaction zone; and, recovering converted hydrocarbons in high concentration.

2. Method according to claim 1 wherein said conversion conditions are hydrogenating conditions and said predetermined temperature is less than about 800 F.

3. Method according to claim 2 wherein said predetermined temperature is more than 700 F.

4. Method according to claim 1 wherein the amount of said first liquid stream passed into indirect heat exchange with said second gaseous stream is controlled responsively to said temperature measurement.

5. Method for hydrogenating a sulfur-containing hydrocarbon feedstock which comprises the steps of:

(a) introducing said feedstock at an inlet temperature from 700 F. to 800 F. into a reactor vessel containing hydrogenating catalyst disposed as a fixed bed therein maintained under hydrogenating conditions including the presence of hydrogen and a relatively high pressure;

(b) withdrawing from said vessel an effiuent stream containing hydrogenated hydrocarbons;

(c) passing said effiuent stream into a first separation zone under substantially the same pressure as maintained in said reactor vessel to produce a first vapor stream and a first liquid stream containing hydrogenated hydrocarbons;

(d) measuring the temperature of said first vapor stream;

(e) introducing hereinafter specified liquid quench stream at a temperature from 200 F. to 450 F. directly into the downstream side of said catalyst bed in an amount responsive to said temperature measurement sufiicient to maintain said first vapor fraction at a temperature from 700 F. to 800 F.;

'(f) cooling said first vapor stream to a temperature from F. to F.;

(g) separating the cooled vapor stream in a second separation zone at substantially the same pressure as said first separation zone under conditions sufiicient to provide a second vapor stream comprising hydrogen, and a second liquid stream containing hydrogenated hydrocarbons;

(h) passing a portion of said first liquid stream into indirect heat exchange with at least a portion of said second vapor stream thereby heating said second vapor stream and cooling said first liquid stream;

(i) introducing said cooled liquid stream as quench into said downstream side as specified hereinabove in p (j) recycling said heated second vapor stream to said reactor vessel of Step (a);

(k) recycling another portion of said first liquid stream of Step (0) to combine with said feedstock in Step (l) recovering hydrogenated hydrocarbons in high concentration having reduced sulfur content.

6. Method according to claim 5 wherein said relatively high pressure is from 1000 p.s.i.g. to 3500 p.s.i.g.

7. Method according to claim 6 wherein said feedstock is characterized by having at least 10% by volume boiling above 1050 F.

References Cited UNITED STATES PATENTS DELBERT E. GANTZ, Primary Examiner A. RIMENS, Assistant Examiner US. Cl. X.R. 208111, 143, 213 

